Riesgos derivados del incumplimiento de normas de

Results

DOE published a report discussing the 26 SGIG projects that are implementing advanced voltage and VAR optimization technologies to improve electric distribution system operations. Initial results are based on 8 SGIG projects involving 31 feeders that reported hourly load data, and two projects that provided data on their experiences with conservation voltage reductions for peak periods. Major findings include:

For the 31 feeders for which projects have reported hourly load data, one-half are witnessing line loss reductions in the range of 0 percent to 5 percent, and 5 feeders experienced loss reductions greater than 5 percent. These results are in the range of other industry estimates which indicate that line loss reductions of 5 percent to 10 percent are possible.

In general, feeders with the worst baseline power factors (i.e., those with the highest amount of inductive loads) showed the greatest reductions in line losses. Many of the utilities are targeting their worst performing feeders. However, overcompensation for reactive power was observed in the remaining feeders, which resulted in line loss increases. In these cases, capacitor banks were often operated for voltage support rather than

reactive power compensation.

The initial results for conservation voltage reductions indicate a potential for peak demand reductions of approximately 1 percent to 2.5 percent. These initial results are consistent with the expectations of the projects and results from other studies in the literature. In comparison to energy savings attributable to line loss reductions, conservation voltage reductions have greater impacts on reducing energy requirements.

4.4

Operations and Maintenance Cost Savings from Application of AMI – Initial

Results

DOE published a report discussing the 63 SGIG projects that are installing AMI to improve operational efficiencies and support billing and customer services. Many of the SGIG AMI projects are still in the process of integrating smart meters with billing and other enterprise systems. Fifteen of the projects representing 3.5 million meters reported initial results to DOE based on operational experiences for a one year period from April 1, 2011, to March 31, 2012. Table 7 provides a summary of the initial results for four metrics: meter operations costs, vehicle miles driven, vehicle fuel consumption, and vehicle emissions.

Meter O&M Savings Metrics Range of Percentage Improvements

Change in meter operations cost -13% to -77%

Change in vehicle miles driven, fuel consumption, and CO2

emissions -12% to -59%

Table 7. Initial Results from AMI Operations for 15 SGIG Projects

Improvements were observed for all four metrics but there was variation in the results across the 15 projects. The variations were the result of several factors, including differences in legacy metering systems, meter operations practices, and the sizes and geographies of the service territories. Further analysis of more projects and time periods is needed before the root causes of the variations can be more completely understood. Major findings include:

Cost reductions and productivity improvements observed to date are primarily related to reductions in labor and vehicle costs from remote meter reading, and automation of other billing-related services.

Of the projects that have completed deployment, the utilities with lower customer densities per distribution line-mile observed larger savings per customer served than those with higher customer densities.

Several of the projects had prior experience with the deployment of AMI and its integration with legacy systems. Having previous experience has been beneficial for these projects in getting AMI to operate properly and with a minimum amount of delay, including having fewer customer and systems integration issues.

U.S. Department of Energy | October 2013

2013 SGIG Program Progress Report II | Page 31

4.5

Demand Reductions from the Application of Advanced Metering

Infrastructure, Pricing Programs, and Customer-Based Systems – Initial

Results

DOE published a report on the 62 SGIG projects that are implementing advanced metering, customer systems, and time-based rates to achieve certain demand-side objectives such as peak-load reductions. Initial results focus on the three projects that produced quantitative evaluation reports of peak demand impacts from demand-side operations in the summer of 2011. Table 8 provides a summary of the initial results from the three projects: Oklahoma Gas & Electric (OG&E), Marblehead Municipal Lighting Department (MMLKD), and Sioux Valley Energy (SVE). Collectively, these projects offered time-based rates at that time to about 7,000 customers, and each had the primary objective of reducing electricity consumption during peak periods.

OG&E MMLD SVE

Number of study

participants 6,000 residential customers

500 residential customers 600 mostly residential customers Type of time-based rate(s)

Time-of-use and variable peak pricing with critical peak pricing components

Critical peak pricing Critical peak pricing

Type of customer systems In-home displays, programmable communicating thermostats, web portals

Web portals Web portals

Peak demand reduction during critical peak events

Up to 30% 37% Up to 25%

Customer acceptance Positive experience, many reduced electricity bills

Positive experience, but did not use the web portals often

Interested in continued participation, many reduced electricity bills Table 8. Summary of the Initial Results (Summer 2011)

With two years of data, the OG&E study provides more information on its results than the other two projects. The analysis shows peak demand reductions of as much as 30 percent from a sample of about 6,000 primarily residential customers (including control groups) that used programmable communicating thermostats, in-home displays, and web portals to respond to time-based rates that included combinations of time-of-use, critical peak, and variable peak pricing. Customers reported positive experiences, had few complaints, and many reduced their monthly electricity bills based on the use of these new programs. Based on their two years of

experience, OG&E decided to roll-out its time-based rate programs to approximately 20 percent of its customers (120,000) by 2016, with the aim of deferring investment in about 170 MW of power plant capacity.